capacitor bank protection and control rev615 product guide · settings, it can directly be put into...
TRANSCRIPT
Relion® 615 series
Capacitor Bank Protection and ControlREV615Product Guide
Contents
1. Description..................................................................... 3
2. Standard configurations................................................. 3
3. Protection functions........................................................7
4. Application..................................................................... 7
5. Supported ABB solutions............................................. 10
6. Control......................................................................... 11
7. Measurements............................................................. 12
8. Power quality................................................................12
9. Disturbance recorder....................................................12
10. Event log..................................................................... 12
11. Recorded data............................................................ 13
12. Condition monitoring .................................................. 13
13. Trip-circuit supervision.................................................13
14. Self-supervision...........................................................13
15. Fuse failure supervision............................................... 13
16. Current circuit supervision........................................... 13
17. Access control............................................................ 13
18. Inputs and outputs...................................................... 13
19. Station communication................................................14
20. Technical data.............................................................19
21. Local HMI....................................................................46
22. Mounting methods...................................................... 47
23. Relay case and plug-in unit......................................... 47
24. Selection and ordering data.........................................47
25. Accessories and ordering data.................................... 48
26. Tools...........................................................................49
27. Cyber security............................................................. 50
28. Terminal diagrams.......................................................51
29. Certificates.................................................................. 53
30. References..................................................................53
31. Functions, codes and symbols.................................... 54
32. Document revision history........................................... 57
Disclaimer
The information in this document is subject to change without notice and should not be construed as a commitment by ABB. ABB assumes no responsibility for any errors
that may appear in this document.
© Copyright 2015 ABB.
All rights reserved.
Trademarks
ABB and Relion are registered trademarks of the ABB Group. All other brand or product names mentioned in this document may be trademarks or registered trademarks
of their respective holders.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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1. DescriptionREV615 is a dedicated capacitor bank relay designed for theprotection, control, measurement and supervision of capacitorbanks used for compensation of reactive power in utilitysubstations and industrial power systems. REV615 can also beused for protection of harmonic filter circuits, if the highestsignificant harmonic component is the 11th. REV615 is a
member of ABB’s Relion® product family and part of its 615protection and control product series. The 615 series relays arecharacterized by their compactness and withdrawable-unitdesign.
Re-engineered from the ground up, the 615 series has beendesigned to unleash the full potential of the IEC 61850 standardfor communication and interoperability between substationautomation devices.
The relay provides main protection for single star, double star,and H-bridge connected capacitor banks and harmonic filtersin distribution networks.
Depending on the chosen standard configuration, the relay isadapted for the protection of H-bridge connected or doublestar connected shunt capacitor banks. Once the standardconfiguration relay has been given the application-specificsettings, it can directly be put into service.
The 615 series relays support a range of communicationprotocols including IEC 61850 with Edition 2 support, process
bus according to IEC 61850-9-2 LE, IEC 60870-5-103,
Modbus® and DNP3. Profibus DPV1 communication protocol issupported by using the protocol converter SPA-ZC 302.
2. Standard configurationsREV615 is available in two alternative standard configurations.The standard signal configuration can be altered by means ofthe signal matrix or the graphical application functionality of theProtection and Control IED Manager PCM600. Further, theapplication configuration functionality of PCM600 supports thecreation of multi-layer logic functions using various logicalelements, including timers and flip-flops. By combiningprotection functions with logic function blocks, the relayconfiguration can be adapted to user-specific applicationrequirements.
The relay is delivered from the factory with default connectionsdescribed in the functional diagrams for binary inputs, binaryoutputs, function-to-function connections and alarm LEDs.Some of the supported functions in REV615 must be addedwith the Application Configuration tool to be available in theSignal Matrix tool and in the relay. The positive measuringdirection of directional protection functions is towards theoutgoing feeder.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1 Issued: 2015-10-30
Revision: B
ABB 3
3I
CONDITION MONITORING AND SUPERVISION
ORAND
CONTROL AND INDICATION 1) MEASUREMENT
CAPACITOR BANK PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION
PROTECTION LOCAL HMI
Object Ctrl 2) Ind 3)
CB
DC
ES1) Check availability of binary inputs/outputs
from technical documentation2) Control and indication function for
primary object3) Status indication function for primary object
RL
ClearESCI
O
Configuration ASystemHMITimeAuthorization
RL
ClearESCI
O
U12 0. 0 kVP 0.00 kWQ 0.00 kVAr
IL2 0 A
A
REMARKS
Optionalfunction
No. ofinstances
Alternative function to be defined when ordering
OR
Io/Uo
Calculatedvalue
3×
REV615 A
COMMUNICATION
Protocols: IEC 61850-8-1 Modbus®
IEC 60870-5-103 DNP3Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232Redundant protocols: HSR PRP RSTP
- I, Io- Limit value supervision- Load profile record- RTD/mA measurement (optional)- Symmetrical components
7
-
Analog interface types 1)
Current transformer
Voltage transformer1) Conventional transformer inputs
ALSO AVAILABLE
- Disturbance and fault recorders- Event log and recorded data- High-Speed Output module (optional) - Local/Remote push button on LHMI- Self-supervision- Time synchronization: IEEE 1588 v2,
SNTP, IRIG-B- User management- Web HMI 2×
I2>46
3I>>>50P/51P
3×ARC
50L/50NL
Master TripLockout relay
94/86
3I>/Io>BF51BF/51NBF
PQM3IPQM3I
2×TCSTCM
MCS 3IMCS 3I
CBCMCBCM
OPTSOPTM
18×MAPMAP
6xRTD2xmA
3I>51P-1
2×3I>>
51P-2TD>55TD
3I>3I<51C
Io>>51N-2
Io>>>50N/51N
2×Io>
51N-1
3dI>C51NC-2
dI>C51NC-1
3Ith>T/G/C49T/G/C
Io
Io
3Iunb
Io
1 -
2 3
1 2
Master TripLockout relay
94/86
3×2×
3×
GUID-DFC320F5-AD45-4D28-8632-C3FB2CFDCB06 V3 EN
Figure 1. Functionality overview for standard configuration A
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
4 ABB
CONDITION MONITORING AND SUPERVISION
ORAND
CONTROL AND INDICATION 1) MEASUREMENT
CAPACITOR BANK PROTECTION AND CONTROL RELAY STANDARD CONFIGURATION
PROTECTION LOCAL HMI
Object Ctrl 2) Ind 3)
CB
DC
ES1) Check availability of binary inputs/outputs
from technical documentation2) Control and indication function for
primary object3) Status indication function for primary object
RL
ClearESCI
O
Configuration ASystemHMITimeAuthorization
RL
ClearESCI
O
U12 0. 0 kVP 0.00 kWQ 0.00 kVAr
IL2 0 A
A
REMARKS
Optionalfunction
No. ofinstances
Alternative function to be defined when ordering
OR
Io/Uo
Calculatedvalue
3×
REV615 B
COMMUNICATION
Protocols: IEC 61850-8-1/-9-2LE Modbus®
IEC 60870-5-103 DNP3Interfaces: Ethernet: TX (RJ45), FX (LC) Serial: Serial glass fiber (ST), RS-485, RS-232Redundant protocols: HSR PRP RSTP
- I, U, Io, Uo, P, Q, E, pf, f- Limit value supervision- Load profile record- RTD/mA measurement (optional)- Symmetrical components
7
5
Analog interface types 1)
Current transformer
Voltage transformer1) Conventional transformer inputs
1 -
2 3
1 2
ALSO AVAILABLE
- Disturbance and fault recorders- Event log and recorded data- High-Speed Output module (optional) - Local/Remote push button on LHMI- Self-supervision- Time synchronization: IEEE 1588 v2,
SNTP, IRIG-B- User management- Web HMI
Master TripLockout relay
94/86
PQM3IPQM3I
2×TCSTCM
MCS 3IMCS 3I
CBCMCBCM
OPTSOPTM
18×MAPMAP
2xRTD1xmA
Io>>51N-2
2×Io>→67N-1
Io>>→67N-2
2×3U<27
U2>47O-
U1<47U+
2×3U>59
Uo>59G
FUSEF60
2×I2>46
3I>>>50P/51P
3×ARC
50L/50NL3I>/Io>BF
51BF/51NBF
3I>51P-1
2×3I>>
51P-2TD>55TD
3I>3I<51C
3dI>C51NC-2
dI>C51NC-1
PQM3UPQM3V
PQMUPQMV
Uo>59G
3Ith>T/G/C49T/G/C
3I
3I
Io
Io
Io
Iunb
Io>IEF→67NIEF
UL1
UL2
UL3
UL1UL2UL3 UL1
UL2
UL3
Uo
Uo
3×
2×
Uo
Master TripLockout relay
94/86
3×2×
PQUUBPQVUB
GUID-393D9B25-06C8-42AE-A7D0-642BBCB89DBE V2 EN
Figure 2. Functionality overview for standard configuration B
Table 1. Standard configurations
Description Std. conf.
Capacitor bank overload and unbalance protection, non-directional overcurrent and earth-fault protection and circuit-breakercondition monitoring
A
Capacitor bank overload and unbalance protection, non-directional overcurrent and directional earth-fault protection, voltage andfrequency based protection and measurements, and circuit-breaker condition monitoring
B
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
ABB 5
Table 2. Supported functions
Function IEC 61850 A B
ProtectionThree-phase non-directional overcurrent protection, low stage PHLPTOC 1 1Three-phase non-directional overcurrent protection, high stage PHHPTOC 2 2Three-phase non-directional overcurrent protection, instantaneous stage PHIPTOC 1 1Non-directional earth-fault protection, low stage EFLPTOC 2 Non-directional earth-fault protection, high stage EFHPTOC 1 1Non-directional earth-fault protection, instantaneous stage EFIPTOC 1 Directional earth-fault protection, low stage DEFLPDEF 2Directional earth-fault protection, high stage DEFHPDEF 1Transient/intermittent earth-fault protection INTRPTEF 1 1)
Negative-sequence overcurrent protection NSPTOC 2 2Residual overvoltage protection ROVPTOV 1
22)
Three-phase undervoltage protection PHPTUV 2Three-phase overvoltage protection PHPTOV 2Positive-sequence undervoltage protection PSPTUV 1Negative-sequence overvoltage protection NSPTOV 1Three-phase thermal overload protection, two time constants T2PTTR 1 1Circuit breaker failure protection CCBRBRF 1 1Master trip TRPPTRC 2
(3) 3)2(3) 3)
Arc protection ARCSARC (3) (3)Multipurpose protection MAPGAPC 18 18Three-phase overload protection for shunt capacitor banks COLPTOC 1 1Current unbalance protection for shunt capacitor banks CUBPTOC 1 4) 1 4)
Three-phase current unbalance protection for shunt capacitor banks HCUBPTOC 1 4) 1 4)
Shunt capacitor bank switching resonance protection, current based SRCPTOC 1 1Power qualityCurrent total demand distortion CMHAI (1) 5) (1) 6)
Voltage total harmonic distortion VMHAI (1) 6)
Voltage variation PHQVVR (1) 6)
Voltage unbalance VSQVUB (1) 6)
ControlCircuit-breaker control CBXCBR 1 1Disconnector control DCXSWI 2 2Earthing switch control ESXSWI 1 1Disconnector position indication DCSXSWI 3 3Earthing switch indication ESSXSWI 2 2Condition monitoring and supervisionCircuit-breaker condition monitoring SSCBR 1 1Trip circuit supervision TCSSCBR 2 2Current circuit supervision CCSPVC 1 1Fuse failure supervision SEQSPVC 1Runtime counter for machines and devices MDSOPT 1 1MeasurementDisturbance recorder RDRE 1 1Load profile record LDPRLRC 1 1Fault record FLTRFRC 1 1Three-phase current measurement CMMXU 1 1Sequence current measurement CSMSQI 1 1Residual current measurement RESCMMXU 1 1Three-phase voltage measurement VMMXU 1Residual voltage measurement RESVMMXU 2Sequence voltage measurement VSMSQI 1Three-phase power and energy measurement PEMMXU 1
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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Table 2. Supported functions, continuedFunction IEC 61850 A B
RTD/mA measurement XRGGIO130 (1) (1)Frequency measurement FMMXU 1
IEC 61850-9-2 LE sampled value sending 7)8) SMVSENDER (1)
IEC 61850-9-2 LE sampled value receiving (voltage sharing) 7)8) SMVRCV (1)
OtherMinimum pulse timer (2 pcs) TPGAPC 4 4Minimum pulse timer (2 pcs, second resolution) TPSGAPC 1 1Minimum pulse timer (2 pcs, minute resolution) TPMGAPC 1 1Pulse timer (8 pcs) PTGAPC 2 2Time delay off (8 pcs) TOFGAPC 4 4Time delay on (8 pcs) TONGAPC 4 4Set-reset (8 pcs) SRGAPC 4 4Move (8 pcs) MVGAPC 2 2Generic control point (16 pcs) SPCGAPC 2 2Analog value scaling (4 pcs) SCA4GAPC 4 4Integer value move (4 pcs) MVI4GAPC 1 11, 2, ... = Number of included instances. The instances of a protection function represent the number of identical protection function blocks available in the standardconfiguration.() = optional
1) "Io measured" is always used.2) "Uob measured" is always used.3) Master trip is included and connected to the corresponding HSO in the configuration only when the BIO0007 module is used. If additionally the ARC option is selected, ARCSARC is
connected to the corresponding master trip input in the configuration.4) The Iunb measurement values are taken from this block and put in the Measurent view.5) Power quality option includes only current total demand distortion.6) Power quality option includes current total demand distortion, voltage total harmonic distortion, voltage variation and voltage unbalance.7) Available only with IEC 61850-9-28) Available only with COM0031-0037
3. Protection functionsThe relay offers three-phase overload protection withundercurrent and reconnection inhibit functionality forcapacitors, single or three-phase current-based unbalanceprotection for capacitors including compensation for naturalunbalance and a current-based switching resonanceprotection.
The relay features non-directional overcurrent and thermaloverload protection as well as non-directional earth-faultprotection.
Additionally, the standard configuration B includes directionalearth-fault protection, residual voltage protection, overvoltageprotection and undervoltage protection functions.
Enhanced with optional hardware and software, the relay alsofeatures three light detection channels for arc fault protection ofthe circuit breaker, busbar and cable compartment of metal-enclosed indoor switchgear.
The arc-fault protection sensor interface is available on theoptional communication module. Fast tripping increases staffsafety and security and limits material damage in an arc faultsituation. A binary input and output module can be selected asan option - having three high speed binary outputs (HSO) it
further decreases the total operate time with typically 4...6 mscompared to the normal power outputs.
4. ApplicationREV615 is intended for the protection of capacitor banks usedfor reactive power compensation in utility substations andindustrial power systems. REV615 offers protectionfunctionality especially for H-bridge, double star and single starconnected capacitor banks and the feeder cable.
The protection relay can also be used for the protection ofharmonic filter circuits, if the highest significant harmoniccomponent is the 11th.
Standard configurations A and B offer three-phase overloadprotection, unbalance protection with compensation for naturalunbalance and switching resonance protection for capacitorbanks. An integrated undercurrent function in the overloadprotection function block detects the disconnection of acapacitor bank and inhibits the closing of the circuit breaker aslong as the capacitor bank is still partially discharged. A three-phase thermal overload protection can be used for the thermalprotection of the reactors and resistors in the harmonic filtercircuits. The relay features non-directional overcurrent andearth-fault protection for the feeder cable and the capacitorbank.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
ABB 7
Standard configuration A is pre-configured for H-bridgeconnected capacitor banks. Three-phase current unbalanceprotection is used for unbalance.
Standard configuration B offers directional earth-faultprotection, residual voltage protection, overvoltage protectionand undervoltage protection functions. It is pre-configured fordouble star connected capacitor banks. Single currentunbalance protection is used for unbalance.
The second and third stage of the residual voltage protection inthe standard configuration B can be used as voltage-basedunbalance protection mainly for single star connected capacitorbanks, with unearthed star point. Dedicated voltage input Uobis used for this purpose. This functionality is available instandard configuration B and needs to be configured before it istaken into use.
3I RL
ClearESCI
O
U12 0. 0 kVP 0.00 kWQ 0.00 kVAr
IL2 0 A
A
REV615Std. conf.
ANSI IEC
50L/50NL
50P/51P
51C
51NC-2
51P/51N
55TD
ARC
3I>>>
3I> 3I<
3dI>C
3I>/Io>
TD>
A
Io
3Iunb
GUID-B7F0755C-006A-4806-91D3-8C290EE3ECA0 V1 EN
Figure 3. Protection of a H-bridge connected capacitor bank
Figure 3 illustrates the protection of an H-bridge connectedcapacitor bank. Standard configuration A is used with overload,three-phase connected current unbalance and undercurrent
protection for the capacitor bank. Overcurrent and earth-faultprotection functions are used for protecting the feeder cableand capacitor bank combination.
3I
REV615Std. conf.
ANSI IEC
27/59/59G
50L/50NL
50P/51P
51C
51NC-1
51P/51N
55TD
67N
3U</3U>/Uo>
ARC
3I>>>
3I> 3I<
dI>C
3I>/Io>
TD>
Io>→
B
3U Uo
RL
ClearESCI
O
U12 0. 0 kVP 0.00 kWQ 0.00 kVAr
IL2 0 A
A
Io
Iunb
GUID-5F33A1B7-2B6F-4CFA-9DD6-71E633C46846 V1 EN
Figure 4. Protection of a double star connected capacitor bank in a distribution network with a compensated or isolated neutral
Protection of a double star connected capacitor bank in adistribution network with a compensated or isolated neutral isshown in Figure 4. Standard configuration B is used withoverload, single phase connected current unbalance and
undercurrent protection for the capacitor bank. Overcurrentand directional earth-fault protetion functions are used forprotecting the feeder cable and capacitor bank combination.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
8 ABB
3U Uo
RL
ClearESCI
O
U12 0. 0 kVP 0.00 kWQ 0.00 kVAr
IL2 0 A
A
3I
REV615Std. conf.
ANSI IEC
27/59/59G
49T
50L/50NL
50P/51P
51C
51NC-2
51P/51N
55TD
3U</3U>/Uo>
3Ith>T
ARC
3I>>>
3I> 3I<
3dI>C
3I>/Io>
TD>
BIo
3Iunb
GUID-30461537-C53B-460B-BA27-9667D6977F77 V1 EN
Figure 5. Protection of a harmonic filter circuit in an industrial network
Figure 5 illustrates the protection of a harmonic filter circuit in anindustrial network. Standard configuration B is used withoverload, three-phase connected current unbalance andundercurrent protection for the harmonic filter and with an
additional thermal protection mainly for the coil. Overcurrentand earth-fault protection functions are used for protecting thefeeder cable and harmonic filter circuit combination.
3U Uo
RL
ClearESCI
O
U12 0. 0 kVP 0.00 kWQ 0.00 kVAr
IL2 0 A
A
3I
REV615Std. conf.
ANSI IEC
27/59/59G
50L/50NL
50P/51P
51C
51P
55TD
67N
3U</3U>/Uo>
ARC
3I>>>
3I> 3I<
3I>
TD>
Io>→
B
Uob
Io
GUID-9C6F9938-FB13-4615-842A-9606411B47FC V1 EN
Figure 6. Protection of a single star connected capacitor bank
The protection of a single star connected capacitor bank isshown in Figure 6. Standard configuration B is used withoverload, voltage-based unbalance (Uob) and undercurrent
protection for the capacitor bank. Overcurrent and earth-faultprotection functions are used for protecting the feeder cableand the capacitor bank combination.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
ABB 9
5. Supported ABB solutionsABB’s 615 series protection and control relays together withthe Substation Automation Unit COM600 constitute a genuineIEC 61850 solution for reliable power distribution in utility andindustrial power systems. To facilitate and streamline thesystem engineering, ABB's relays are supplied withconnectivity packages. The connectivity packages include acompilation of software and relay-specific information,including single-line diagram templates and a full relay datamodel. The data model also includes event and parameter lists.With the connectivity packages, the relays can be readilyconfigured using PCM600 and integrated with the SubstationAutomation Unit COM600 or the network control andmanagement system MicroSCADA Pro.
The 615 series relays offer native support for IEC 61850 Edition2 also including binary and analog horizontal GOOSEmessaging. In addition, process bus with the sending ofsampled values of analog currents and voltages and thereceiving of sampled values of voltages is supported.Compared to traditional hard-wired, inter-device signaling,peer-to-peer communication over a switched Ethernet LANoffers an advanced and versatile platform for power systemprotection. Among the distinctive features of the protectionsystem approach, enabled by the full implementation of the IEC61850 substation automation standard, are fastcommunication capability, continuous supervision of theintegrity of the protection and communication system, and aninherent flexibility regarding reconfiguration and upgrades. Thisprotection relay series is able to optimally utilize interoperabilityprovided by the IEC 61850 Edition 2 features.
At substation level, COM600 uses the data content of the bay-level devices to enhance substation level functionality. COM600
features a Web browser-based HMI, which provides acustomizable graphical display for visualizing single-line mimicdiagrams for switchgear bay solutions. The SLD feature isespecially useful when 615 series relays without the optionalsingle-line diagram feature are used. The Web HMI of COM600also provides an overview of the whole substation, includingrelay-specific single-line diagrams, which makes informationeasily accessible. Substation devices and processes can alsobe remotely accessed through the Web HMI, which improvespersonnel safety.
In addition, COM600 can be used as a local data warehouse forthe substation's technical documentation and for the networkdata collected by the devices. The collected network datafacilitates extensive reporting and analyzing of network faultsituations, by using the data historian and event handlingfeatures of COM600. The history data can be used for accuratemonitoring of process and equipment performance, usingcalculations based on both real-time and history values. Abetter understanding of the process dynamics is achieved bycombining time-based process measurements with productionand maintenance events.
COM600 can also function as a gateway and provide seamlessconnectivity between the substation devices and network-levelcontrol and management systems, such as MicroSCADA Proand System 800xA.
GOOSE Analyzer interface in COM600 enables the followingand analyzing the horizontal IEC 61850 application duringcommissioning and operation at station level. It logs all GOOSEevents during substation operation to enable improved systemsupervision.
Table 3. Supported ABB solutions
Product Version
Substation Automation Unit COM600 4.0 SP1 or later
4.1 or later (Edition 2)
MicroSCADA Pro SYS 600 9.3 FP2 or later
9.4 or later (Edition 2)
System 800xA 5.1 or later
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
10 ABB
PCM600Ethernet switch
Utility: IEC 60870-5-104Industry: OPC
COM600Web HMI
ABBMicroSCADA Pro/
System 800xA
Analog and binary horizontal GOOSE communication IEC 61850
PCM600Ethernet switch
COM600Web HMI
Analog and binary horizontal GOOSE communication IEC 61850
GUID-4D002AA0-E35D-4D3F-A157-01F1A3044DDB V2 EN
Figure 7. ABB power system example using Relion relays, Substation Automation Unit COM600 and MicroSCADA Pro/System 800xA
6. ControlREV615 integrates functionality for the control of a circuitbreaker via the front panel HMI or by means of remote controls.In addition to the circuit breaker control the relay features twocontrol blocks intended for motor-operated control ofdisconnectors or circuit breaker truck and their positionindications.
The relay has one control block intended for motor-operatedcontrol of one earthing switch control and its positionindication. Two physical binary inputs and two physical binaryoutputs are needed in the relay for each controllable primarydevice taken into use. The number of unused binary inputs andbinary outputs varies, depending on the chosen standardconfiguration of the relay. Further, some standardconfigurations offer optional hardware modules that increasethe number of available binary inputs and outputs.
If the amount of available binary inputs or outputs of the chosenstandard configuration is not sufficient, the standardconfiguration can be modified to release some binary inputs oroutputs which have originally been configured for other
purposes, when applicable, or an external input or outputmodule, for example, RIO600 can be integrated to the relay.The binary inputs and outputs of the external I/O module can beused for the less time critical binary signals of the application.The integration enables releasing of some initially reservedbinary inputs and outputs of the relay in the standardconfiguration.
The suitability of the binary outputs of the relay which have beenselected for controlling of primary devices should be carefullyverified, for example the make and carry as well as the breakingcapacity. If the requirements for the control-circuit of theprimary device are not met, the use of external auxiliary relaysshould be considered.
The optional large graphical LCD of the relay's HMI includes asingle-line diagram (SLD) with position indication for therelevant primary devices. Interlocking schemes required by theapplication are configured using the signal matrix or theapplication configuration functionality of PCM600.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
ABB 11
7. MeasurementsThe relay continuously measures the phase currents, the singleor three-phase unbalance currents (with the natural unbalancecurrent compensated), the symmetrical components of thephase currents and the residual current.
The standard configuration B includes voltage measurements.It measures the residual voltage, the phase voltages, thevoltage sequence components and frequency. It also measuresthe capacitor bank unbalance voltage if the Uob is connectedand the relay is configured accordingly. This voltagemeasurement is called residual voltage measurement, instance2. The relay offers three-phase power and energy measurementincluding power factor.
In addition, the relay calculates the demand value of currentover a user-selectable preset time frames, the thermal overloadof the protected object, and the phase unbalance value basedon the ratio between the negative-sequence and positive-sequence current.
The values measured can be accessed locally via the userinterface on the relay's front panel or remotely via thecommunication interface of the relay. The values can also beaccessed locally or remotely using the Web browser-baseduser interface.
The relay is provided with a load profile recorder. The loadprofile feature stores the historical load data captured at aperiodical time interval (demand interval). The records are inCOMTRADE format.
8. Power qualityIn the EN standards, power quality is defined through thecharacteristics of the supply voltage. Transients, short-durationand long-duration voltage variations and unbalance andwaveform distortions are the key characteristics describingpower quality. The distortion monitoring functions are used formonitoring the current total demand distortion and the voltagetotal harmonic distortion.
Power quality monitoring is an essential service that utilities canprovide for their industrial and key customers. Not only can amonitoring system provide information about systemdisturbances and their possible causes, it can also detectproblem conditions throughout the system before they causecustomer complaints, equipment malfunctions and evenequipment damage or failure. Power quality problems are notlimited to the utility side of the system. In fact, the majority ofpower quality problems are localized within customer facilities.Thus, power quality monitoring is not only an effective customerservice strategy but also a way to protect a utility's reputationfor quality power and service.
The protection relay has the following power quality monitoringfunctions.
• Voltage variation• Voltage unbalance• Current harmonics• Voltage harmonics
The voltage unbalance and voltage variation functions are usedfor measuring short-duration voltage variations and monitoringvoltage unbalance conditions in power transmission anddistribution networks.
The voltage and current harmonics functions provide a methodfor monitoring the power quality by means of the currentwaveform distortion and voltage waveform distortion. Thefunctions provides a short-term 3-second average and a long-term demand for total demand distortion TDD and totalharmonic distortion THD.
9. Disturbance recorderThe relay is provided with a disturbance recorder with up to 12analog and 64 binary signal channels. The analog channels canbe set to record either the waveform or the trend of the currentsand voltages measured.
The analog channels can be set to trigger the recording functionwhen the measured value falls below, or exceeds, the setvalues. The binary signal channels can be set to start arecording either on the rising or the falling edge of the binarysignal or on both.
By default, the binary channels are set to record external orinternal relay signals, for example, the start or trip signals of therelay stages, or external blocking or control signals. Binary relaysignals, such as protection start and trip signals, or an externalrelay control signal via a binary input, can be set to trigger therecording. Recorded information is stored in a non-volatilememory and can be uploaded for subsequent fault analysis.
10. Event logTo collect sequence-of-events information, the relay has a non-volatile memory with a capacity of storing 1024 events withassociated time stamps. The non-volatile memory retains itsdata also in case the relay temporarily loses its auxiliary supply.The event log facilitates detailed pre- and post-fault analyses offeeder faults and disturbances. The increased capacity toprocess and store data and events in the relay offersprerequisites to support the growing information demand offuture network configurations.
The sequence-of-events information can be accessed eitherlocally via the user interface on the relay's front panel, orremotely via the communication interface of the relay. Theinformation can also be accessed using the Web browser-based user interface, either locally or remotely.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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11. Recorded dataThe relay has the capacity to store the records of the 128 latestfault events. The records enable the user to analyze the powersystem events. Each record includes current, voltage and anglevalues, time stamp and so on. The fault recording can betriggered by the start signal or the trip signal of a protectionblock, or by both. The available measurement modes includeDFT, RMS and peak-to-peak. Fault records store relaymeasurement values at the moment when any protectionfunction starts. In addition, the maximum demand current withtime stamp is separately recorded. The records are stored inthe non-volatile memory.
12. Condition monitoringThe condition monitoring functions of the relay constantlymonitor the performance and the condition of the circuitbreaker. The monitoring comprises the spring charging time,SF6 gas pressure, the travel time and the inactivity time of thecircuit breaker.
The monitoring functions provide operational circuit breakerhistory data, which can be used for scheduling preventivecircuit breaker maintenance.
In addition, the relay includes a runtime counter for monitoringof how many hours a protected device has been in operationthus enabling scheduling of time-based preventivemaintenance of the device.
13. Trip-circuit supervisionThe trip-circuit supervision continuously monitors theavailability and operability of the trip circuit. It provides open-circuit monitoring both when the circuit breaker is in its closedand in its open position. It also detects loss of circuit-breakercontrol voltage.
14. Self-supervisionThe relay’s built-in self-supervision system continuouslymonitors the state of the relay hardware and the operation ofthe relay software. Any fault or malfunction detected is used foralerting the operator.
A permanent relay fault blocks the protection functions toprevent incorrect operation.
15. Fuse failure supervisionIn the standard configuration B, the relay includes fuse failuresupervision functionality. The fuse failure supervision detectsfailures between the voltage measurement circuit and the relay.The failures are detected either by the negative sequence-based algorithm or by the delta voltage and delta currentalgorithm. Upon the detection of a failure, the fuse failure
supervision function activates an alarm and blocks voltage-dependent protection functions from unintended operation.
16. Current circuit supervisionThe relay includes current circuit supervision. Current circuitsupervision is used for detecting faults in the currenttransformer secondary circuits. On detecting of a fault thecurrent circuit supervision function activates an alarm LED andblocks certain protection functions to avoid unintendedoperation. The current circuit supervision function calculatesthe sum of the phase currents from the protection cores andcompares the sum with the measured single reference currentfrom a core balance current transformer or from separate coresin the phase current transformers.
17. Access controlTo protect the relay from unauthorized access and to maintaininformation integrity, the relay is provided with a four-level, role-based authentication system with administrator-programmableindividual passwords for the viewer, operator, engineer andadministrator level. The access control applies to the front-panel user interface, the Web browser-based user interfaceand PCM600.
18. Inputs and outputsThe relay is equipped with three phase-current inputs, threeunbalance-current inputs and one residual-current input fornon-directional earth-fault protection.
In the standard configuration B, the relay is additionallyequipped with three phase-voltage inputs, one residual voltageinput for directional earth-fault protection and one voltage input(Uob) that can be used for voltage based unbalance protection.
The rated level of the current inputs is 1/5 A and selectable inthe relay software. The three phase-voltage inputs and theresidual-voltage inputs cover the rated voltages 60-210 V. Bothphase-to-phase voltages and phase-to-earth voltages can beconnected. The binary input thresholds 16…176 V DC areselected by adjusting the relay’s parameter settings.
All binary inputs and outputs contacts are freely configurablewith the signal matrix or application configuration functionalityof PCM600.
Please refer to the Input/output overview table and the terminaldiagrams for more detailed information about the inputs andoutputs.
Optionally, a binary input and output module can be selected. Ithas three high speed binary outputs (HSO) and it decreases thetotal operate time with typically 4...6 ms compared to thenormal power outputs.
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Table 4. Input/output overview
Std. conf. Order code digit Analog channels Binary channels
5-6 7-8 CT VT BI BO RTD mA
A
BA
BA 7 - 8 4 PO + 6 SO - -
BB 7 - 14 4 PO + 9 SO - -
FD 7 - 8 4 PO + 2 SO+ 3 HSO
- -
FF 7 - 14 4 PO + 5 SO+ 3 HSO
- -
BG
BA 7 - 8 4 PO + 6 SO 6 2
FD 7 - 8 4 PO + 2 SO+ 3 HSO
6 2
B
BC
AD 7 5 12 4 PO + 6 SO - -
FE 7 5 12 4 PO + 2 SO+ 3 HSO
- -
BE
BA 7 5 8 4 PO + 6 SO 2 1
FD 7 5 8 4 PO + 2 SO+ 3 HSO
2 1
As an option for standard configuration B, the relay has twoRTD inputs and 1 mA input. The relay measures signals such astemperature via the two RTD inputs and mA inputs using atransducer. The values can, apart from measuring and
monitoring purposes, be used for tripping and alarm purposesusing the multipurpose protection functions. The temperaturesignal can also be used for ambient temperature information forthe thermal protection function.
19. Station communicationThe relay supports a range of communication protocolsincluding IEC 61850 Edition 2, IEC 61850-9-2 LE, IEC
60870-5-103, Modbus® and DNP3. Profibus DPV1communication protocol is supported with using the protocolconverter SPA-ZC 302. Operational information and controlsare available through these protocols. However, somecommunication functionality, for example, horizontalcommunication between the relays, is only enabled by the IEC61850 communication protocol.
The IEC 61850 protocol is a core part of the relay as theprotection and control application is fully based on standardmodelling. The relay supports Edition 2 and Edition 1 versionsof the standard. With Edition 2 support, the relay has the latestfunctionality modelling for substation applications and the bestinteroperability for modern substations. It incorporates also thefull support of standard device mode functionality supportingdifferent test applications. Control applications can utilize thenew safe and advanced station control authority feature.
The IEC 61850 communication implementation supportsmonitoring and control functions. Additionally, parametersettings, disturbance recordings and fault records can beaccessed using the IEC 61850 protocol. Disturbancerecordings are available to any Ethernet-based application in
the standard COMTRADE file format. The relay supportssimultaneous event reporting to five different clients on thestation bus. The relay can exchange data with other devicesusing the IEC 61850 protocol.
The relay can send binary and analog signals to other devicesusing the IEC 61850-8-1 GOOSE (Generic Object OrientedSubstation Event) profile. Binary GOOSE messaging can, forexample, be employed for protection and interlocking-basedprotection schemes. The relay meets the GOOSE performancerequirements for tripping applications in distributionsubstations, as defined by the IEC 61850 standard (<10 msdata exchange between the devices). The relay also supportsthe sending and receiving of analog values using GOOSEmessaging. Analog GOOSE messaging enables easy transfer ofanalog measurement values over the station bus, thusfacilitating for example the sending of measurement valuesbetween the relays when controlling parallel runningtransformers.
The relay also supports IEC 61850 process bus by sendingsampled values of analog currents and voltages and byreceiving sampled values of voltages. With this functionality thegalvanic interpanel wiring can be replaced with Ethernetcommunication. The measured values are transferred assampled values using IEC 61850-9-2 LE protocol. The intended
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application for sampled values shares the voltages to other 615series relays, having voltage based functions and 9-2 support.615 relays with process bus based applications use IEEE 1588for high accuracy time synchronization.
For redundant Ethernet communication, the relay offers eithertwo optical or two galvanic Ethernet network interfaces. A thirdport with galvanic Ethernet network interface is also available.The third Ethernet interface provides connectivity for any otherEthernet device to an IEC 61850 station bus inside a switchgearbay, for example connection of a Remote I/O. Ethernet networkredundancy can be achieved using the high-availabilityseamless redundancy (HSR) protocol or the parallelredundancy protocol (PRP) or a with self-healing ring usingRSTP in managed switches. Ethernet redundancy can beapplied to Ethernet-based IEC 61850, Modbus and DNP3protocols.
The IEC 61850 standard specifies network redundancy whichimproves the system availability for the substation
communication. The network redundancy is based on twocomplementary protocols defined in the IEC 62439-3 standard:PRP and HSR protocols. Both the protocols are able toovercome a failure of a link or switch with a zero switch-overtime. In both the protocols, each network node has twoidentical Ethernet ports dedicated for one network connection.The protocols rely on the duplication of all transmittedinformation and provide a zero switch-over time if the links orswitches fail, thus fulfilling all the stringent real-timerequirements of substation automation.
In PRP, each network node is attached to two independentnetworks operated in parallel. The networks are completelyseparated to ensure failure independence and can havedifferent topologies. The networks operate in parallel, thusproviding zero-time recovery and continuous checking ofredundancy to avoid failures.
Ethernet switchIEC 61850 PRPEthernet switch
REF615 REF620 RET620 REM620 REF615
SCADACOM600
GUID-334D26B1-C3BD-47B6-BD9D-2301190A5E9D V1 EN
Figure 8. Parallel redundancy protocol (PRP) solution
HSR applies the PRP principle of parallel operation to a singlering. For each message sent, the node sends two frames, onethrough each port. Both the frames circulate in oppositedirections over the ring. Every node forwards the frames itreceives from one port to another to reach the next node. Whenthe originating sender node receives the frame it sent, the
sender node discards the frame to avoid loops. The HSR ringwith 615 series relays supports the connection of up to 30relays. If more than 30 relays are to be connected, it isrecommended to split the network into several rings toguarantee the performance for real-time applications.
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Ethernet switch
RedundancyBox
IEC 61850 HSR
RedundancyBox
RedundancyBox
REF615 REF620 RET620 REM620 REF615
SCADA Devices not supporting HSRCOM600
GUID-7996332D-7FC8-49F3-A4FE-FB4ABB730405 V1 EN
Figure 9. High availability seamless redundancy (HSR) solution
The choice between the HSR and PRP redundancy protocolsdepends on the required functionality, cost and complexity.
The self-healing Ethernet ring solution enables a cost-efficientcommunication ring controlled by a managed switch withstandard Rapid Spanning Tree Protocol (RSTP) support. Themanaged switch controls the consistency of the loop, routesthe data and corrects the data flow in case of a communication
switch-over. The relays in the ring topology act as unmanagedswitches forwarding unrelated data traffic. The Ethernet ringsolution supports the connection of up to 30 615 series relays.If more than 30 relays are to be connected, it is recommendedto split the network into several rings. The self-healing Ethernetring solution avoids single point of failure concerns andimproves the reliability of the communication.
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Managed Ethernet switchwith RSTP support
Managed Ethernet switchwith RSTP support
Client BClient A
Network ANetwork B
GUID-AB81C355-EF5D-4658-8AE0-01DC076E519C V4 EN
Figure 10. Self-healing Ethernet ring solution
All communication connectors, except for the front portconnector, are placed on integrated optional communicationmodules. The relay can be connected to Ethernet-basedcommunication systems via the RJ-45 connector (100Base-TX)or the fiber optic LC connector (100Base-FX). If connection toserial bus is required, the 9-pin RS-485 screw-terminal can beused. An optional serial interface is available for RS-232communication.
Modbus implementation supports RTU, ASCII and TCP modes.Besides standard Modbus functionality, the relay supportsretrieval of time-stamped events, changing the active settinggroup and uploading of the latest fault records. If a ModbusTCP connection is used, five clients can be connected to therelay simultaneously. Further, Modbus serial and Modbus TCPcan be used in parallel, and if required both IEC 61850 andModbus protocols can be run simultaneously.
The IEC 60870-5-103 implementation supports two parallelserial bus connections to two different masters. Besides basicstandard functionality, the relay supports changing of the activesetting group and uploading of disturbance recordings in IEC60870-5-103 format. Further, IEC 60870-5-103 can be used atthe same time with the IEC 61850 protocol.
DNP3 supports both serial and TCP modes for connection upto five masters. Changing of the active setting and reading fault
records are supported. DNP serial and DNP TCP can be used inparallel. If required, both IEC 61850 and DNP protocols can berun simultaneously.
615 series supports Profibus DPV1 with support of SPA-ZC302 Profibus adapter. If Profibus is required the relay must beordered with Modbus serial options. Modbus implementationincludes SPA-protocol emulation functionality. Thisfunctionality enables connection to SPA-ZC 302.
When the relay uses the RS-485 bus for the serialcommunication, both two- and four wire connections aresupported. Termination and pull-up/down resistors can beconfigured with jumpers on the communication card so externalresistors are not needed.
The relay supports the following time synchronization methodswith a time-stamping resolution of 1 ms.
Ethernet-based• SNTP (Simple Network Time Protocol)
With special time synchronization wiring• IRIG-B (Inter-Range Instrumentation Group - Time Code
Format B)
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The relay supports the following high accuracy timesynchronization method with a time-stamping resolution of 4 µsrequired especially in process bus applications.• PTP (IEEE 1588) v2 with Power Profile
The IEEE 1588 support is included in all variants having aredundant Ethernet communication module.
IEEE 1588 v2 features• Ordinary Clock with Best Master Clock algorithm• One-step Transparent Clock for Ethernet ring topology• 1588 v2 Power Profile• Receive (slave): 1-step/2-step• Transmit (master): 1-step
• Layer 2 mapping• Peer to peer delay calculation• Multicast operation
Required accuracy of grandmaster clock is +/-1 µs. The relaycan work as a master clock per BMC algorithm if the externalgrandmaster clock is not available for short term.
The IEEE 1588 support is included in all variants having aredundant Ethernet communication module.
In addition, the relay supports time synchronization viaModbus, DNP3 and IEC 60870-5-103 serial communicationprotocols.
Table 5. Supported station communication interfaces and protocols
Interfaces/Protocols Ethernet Serial
100BASE-TX RJ-45 100BASE-FX LC RS-232/RS-485 Fiber optic ST
IEC 61850-8-1 ● ● - -
IEC 61850-9-2 LE ● ● - -
MODBUS RTU/ASCII - - ● ●
MODBUS TCP/IP ● ● - -
DNP3 (serial) - - ● ●
DNP3 TCP/IP ● ● - -
IEC 60870-5-103 - - ● ●● = Supported
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20. Technical data
Table 6. Dimensions
Description Value
Width Frame 177 mm
Case 164 mm
Height Frame 177 mm (4U)
Case 160 mm
Depth 201 mm (153 + 48 mm)
Weight Complete protection relay 4.1 kg
Plug-in unit only 2.1 kg
Table 7. Power supply
Description Type 1 Type 2
Nominal auxiliary voltage Un 100, 110, 120, 220, 240 V AC, 50 and 60 Hz 24, 30, 48, 60 V DC
48, 60, 110, 125, 220, 250 V DC
Maximum interruption time in the auxiliaryDC voltage without resetting the relay
50 ms at Un
Auxiliary voltage variation 38...110% of Un (38...264 V AC) 50...120% of Un (12...72 V DC)
80...120% of Un (38.4...300 V DC)
Start-up threshold 19.2 V DC (24 V DC × 80%)
Burden of auxiliary voltage supply underquiescent (Pq)/operating condition
DC <12.0 W (nominal)/<18.0 W (max)AC <16.0 W (nominal)/<21.0 W (max)
DC <12.0 W (nominal)/<18.0 W (max)
Ripple in the DC auxiliary voltage Max 15% of the DC value (at frequency of 100 Hz)
Fuse type T4A/250 V
Table 8. Energizing inputs
Description Value
Rated frequency 50/60 Hz
Current inputs Rated current, In 0.2/1 A1) 1/5 A2)
Thermal withstand capability:
• Continuously 4 A 20 A
• For 1 s 100 A 500 A
Dynamic current withstand:
• Half-wave value 250 A 1250 A
Input impedance <100 mΩ <20 mΩ
Voltage inputs Rated voltage 60...210 V AC
Voltage withstand:
• Continuous 240 V AC
• For 10 s 360 V AC
Burden at rated voltage <0.05 VA
1) Ordering option for residual current input2) Residual current and/or phase current
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Table 9. Binary inputs
Description Value
Operating range ±20% of the rated voltage
Rated voltage 24...250 V DC
Current drain 1.6...1.9 mA
Power consumption 31.0...570.0 mW
Threshold voltage 16...176 V DC
Reaction time <3 ms
Table 10. Signal output X100: SO1
Description Value
Rated voltage 250 V AC/DC
Continuous contact carry 5 A
Make and carry for 3.0 s 15 A
Make and carry for 0.5 s 30 A
Breaking capacity when the control-circuit time constant L/R<40 ms 1 A/0.25 A/0.15 A
Minimum contact load 100 mA at 24 V AC/DC
Table 11. Signal outputs and IRF output
Description Value
Rated voltage 250 V AC/DC
Continuous contact carry 5 A
Make and carry for 3.0 s 10 A
Make and carry 0.5 s 15 A
Breaking capacity when the control-circuit time constant L/R<40 ms, at48/110/220 V DC
1 A/0.25 A/0.15 A
Minimum contact load 10 mA at 5 V AC/DC
Table 12. Double-pole power output relays with TCS function
Description Value
Rated voltage 250 V AC/DC
Continuous contact carry 8 A
Make and carry for 3.0 s 15 A
Make and carry for 0.5 s 30 A
Breaking capacity when the control-circuit time constant L/R<40 ms, at48/110/220 V DC (two contacts connected in series)
5 A/3 A/1 A
Minimum contact load 100 mA at 24 V AC/DC
Trip-circuit supervision (TCS):
• Control voltage range 20...250 V AC/DC
• Current drain through the supervision circuit ~1.5 mA
• Minimum voltage over the TCS contact 20 V AC/DC (15...20 V)
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Table 13. Single-pole power output relays
Description Value
Rated voltage 250 V AC/DC
Continuous contact carry 8A
Make and carry for 3.0 s 15 A
Make and carry for 0.5 s 30 A
Breaking capacity when the control-circuit time constant L/R<40 ms, at48/110/220 V DC
5 A/3 A/1 A
Minimum contact load 100 mA at 24 V AC/DC
Table 14. High-speed output HSO with BIO0007
Description Value
Rated voltage 250 V AC/DC
Continuous contact carry 6 A
Make and carry for 3.0 s 15 A
Make and carry for 0.5 s 30 A
Breaking capacity when the control-circuit time constant L/R <40 ms, at48/110/220 V DC
5 A/3 A/1 A
Operate time <1 ms
Reset <20 ms, resistive load
Table 15. Front port Ethernet interfaces
Ethernet interface Protocol Cable Data transfer rate
Front TCP/IP protocol Standard Ethernet CAT 5 cable with RJ-45 connector 10 MBits/s
Table 16. IRIG-B
Description Value
IRIG time code format B004, B0051)
Isolation 500V 1 min
Modulation Unmodulated
Logic level 5 V TTL
Current consumption <4 mA
Power consumption <20 mW
1) According to the 200-04 IRIG standard
Table 17. Degree of protection of flush-mounted protection relay
Description Value
Front side IP 54
Rear side, connection terminals IP 20
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Table 18. Environmental conditions
Description Value
Operating temperature range -25...+55ºC (continuous)
Short-time service temperature range -40...+85ºC (<16h)1)2)
Relative humidity <93%, non-condensing
Atmospheric pressure 86...106 kPa
Altitude Up to 2000 m
Transport and storage temperature range -40...+85ºC
1) Degradation in MTBF and HMI performance outside the temperature range of -25...+55 ºC2) For relays with an LC communication interface the maximum operating temperature is +70 ºC
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Table 19. Electromagnetic compatibility tests
Description Type test value Reference
1 MHz/100 kHz burst disturbance test IEC 61000-4-18IEC 60255-26, class IIIIEEE C37.90.1-2002
• Common mode 2.5 kV
• Differential mode 2.5 kV
3 MHz, 10 MHz and 30 MHz burst disturbancetest
IEC 61000-4-18IEC 60255-26, class III
• Common mode 2.5 kV
Electrostatic discharge test IEC 61000-4-2IEC 60255-26IEEE C37.90.3-2001
• Contact discharge 8 kV
• Air discharge 15 kV
Radio frequency interference test
10 V (rms)f = 150 kHz...80 MHz
IEC 61000-4-6IEC 60255-26, class III
10 V/m (rms)f = 80...2700 MHz
IEC 61000-4-3IEC 60255-26, class III
10 V/mf = 900 MHz
ENV 50204IEC 60255-26, class III
20 V/m (rms)f = 80...1000 MHz
IEEE C37.90.2-2004
Fast transient disturbance test IEC 61000-4-4IEC 60255-26IEEE C37.90.1-2002
• All ports 4 kV
Surge immunity test IEC 61000-4-5IEC 60255-26
• Communication 1 kV, line-to-earth
• Other ports 4 kV, line-to-earth2 kV, line-to-line
Power frequency (50 Hz) magnetic fieldimmunity test
IEC 61000-4-8
• Continuous• 1...3 s
300 A/m1000 A/m
Pulse magnetic field immunity test 1000 A/m6.4/16 µs
IEC 61000-4-9
Damped oscillatory magnetic field immunity test IEC 61000-4-10
• 2 s 100 A/m
• 1 MHz 400 transients/s
Voltage dips and short interruptions 30%/10 ms60%/100 ms60%/1000 ms>95%/5000 ms
IEC 61000-4-11
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Table 19. Electromagnetic compatibility tests, continued
Description Type test value Reference
Power frequency immunity test Binary inputs only IEC 61000-4-16IEC 60255-26, class A
• Common mode 300 V rms
• Differential mode 150 V rms
Conducted common mode disturbances 15 Hz...150 kHzTest level 3 (10/1/10 V rms)
IEC 61000-4-16
Emission tests EN 55011, class AIEC 60255-26CISPR 11CISPR 12
• Conducted
0.15...0.50 MHz <79 dB (µV) quasi peak<66 dB (µV) average
0.5...30 MHz <73 dB (µV) quasi peak<60 dB (µV) average
• Radiated
30...230 MHz <40 dB (µV/m) quasi peak, measured at 10 mdistance
230...1000 MHz <47 dB (µV/m) quasi peak, measured at 10 mdistance
1…3 GHz < 76 dB (µV/m) peak< 56 dB (µV/m) average, measured at 3 mdistance
3…6 GHz < 80 dB (µV/m) peak< 60 dB (µV/m) average, measured at 3 mdistance
Table 20. Insulation tests
Description Type test value Reference
Dielectric tests 2 kV, 50 Hz, 1 min500 V, 50 Hz, 1 min, communication
IEC 60255-27
Impulse voltage test 5 kV, 1.2/50 μs, 0.5 J1 kV, 1.2/50 μs, 0.5 J, communication
IEC 60255-27
Insulation resistance measurements >100 MΩ, 500 V DC IEC 60255-27
Protective bonding resistance <0.1 Ω, 4 A, 60 s IEC 60255-27
Table 21. Mechanical tests
Description Reference Requirement
Vibration tests (sinusoidal) IEC 60068-2-6 (test Fc)IEC 60255-21-1
Class 2
Shock and bump test IEC 60068-2-27 (test Ea shock)IEC 60068-2-29 (test Eb bump)IEC 60255-21-2
Class 2
Seismic test IEC 60255-21-3 Class 2
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Table 22. Environmental tests
Description Type test value Reference
Dry heat test • 96 h at +55ºC IEC 60068-2-2
Dry cold test • 96 h at -25ºC• 16 h at -40ºC
IEC 60068-2-1
Damp heat test • 6 cycles (12 h + 12 h) at +25°C…+55°C,humidity >93%
IEC 60068-2-30
Change of temperature test • 5 cycles (3 h + 3 h)at -25°C...+55°C
IEC60068-2-14
Storage test • 96 h at -40ºC• 96 h at +85ºC
IEC 60068-2-1IEC 60068-2-2
Table 23. Product safety
Description Reference
LV directive 2006/95/EC
Standard EN 60255-27 (2013)EN 60255-1 (2009)
Table 24. EMC compliance
Description Reference
EMC directive 2004/108/EC
Standard EN 60255-26 (2013)
Table 25. RoHS compliance
Description
Complies with RoHS directive 2002/95/EC
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Protection functions
Table 26. Three-phase non-directional overcurrent protection (PHxPTOC)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
PHLPTOC ±1.5% of the set value or ±0.002 × In
PHHPTOCandPHIPTOC
±1.5% of set value or ±0.002 × In(at currents in the range of 0.1…10 × In)±5.0% of the set value(at currents in the range of 10…40 × In)
Start time 1)2) Minimum Typical Maximum
PHIPTOC:IFault = 2 × set Start valueIFault = 10 × set Start value
16 ms 11 ms
19 ms 12 ms
23 ms 14 ms
PHHPTOC and PHLPTOC:IFault = 2 x set Start value
23 ms
26 ms
29 ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Retardation time <30 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3)
Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppressionP-to-P+backup: No suppression
1) Set Operate delay time = 0,02 s, Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 × In, fn = 50 Hz, fault current in one phasewith nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements
2) Includes the delay of the signal output contact3) Includes the delay of the heavy-duty output contact
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Table 27. Three-phase non-directional overcurrent protection (PHxPTOC) main settings
Parameter Function Value (Range) Step
Start Value PHLPTOC 0.05...5.00 × In 0.01
PHHPTOC 0.10...40.00 × In 0.01
PHIPTOC 1.00...40.00 × In 0.01
Time multiplier PHLPTOC 0.05...15.00 0.01
PHHPTOC 0.05...15.00 0.01
Operate delay time PHLPTOC 40...200000 ms 10
PHHPTOC 40...200000 ms 10
PHIPTOC 20...200000 ms 10
Operating curve type1) PHLPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19
PHHPTOC Definite or inverse timeCurve type: 1, 3, 5, 9, 10, 12, 15, 17
PHIPTOC Definite time
1) For further reference, see Operation characteristics table
Table 28. Non-directional earth-fault protection (EFxPTOC)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
EFLPTOC ±1.5% of the set value or ±0.002 × In
EFHPTOCandEFIPTOC
±1.5% of set value or ±0.002 × In(at currents in the range of 0.1…10 × In)±5.0% of the set value(at currents in the range of 10…40 × In)
Start time 1)2) Minimum Typical Maximum
EFIPTOC:IFault = 2 × set Start valueIFault = 10 × set Start value
16 ms11 ms
19 ms12 ms
23 ms14 ms
EFHPTOC and EFLPTOC:IFault = 2 × set Start value
23 ms
26 ms
29 ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Retardation time <30 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3)
Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppression
1) Measurement mode = default (depends on stage), current before fault = 0.0 × In, fn = 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on
statistical distribution of 1000 measurements2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 × In, Start value multiples in range of 1.5...20
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Table 29. Non-directional earth-fault protection (EFxPTOC) main settings
Parameter Function Value (Range) Step
Start value EFLPTOC 0.010...5.000 × In 0.005
EFHPTOC 0.10...40.00 × In 0.01
EFIPTOC 1.00...40.00 × In 0.01
Time multiplier EFLPTOC 0.05...15.00 0.01
EFHPTOC 0.05...15.00 0.01
Operate delay time EFLPTOC 40...200000 ms 10
EFHPTOC 40...200000 ms 10
EFIPTOC 20...200000 ms 10
Operating curve type1) EFLPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19
EFHPTOC Definite or inverse timeCurve type: 1, 3, 5, 9, 10, 12, 15, 17
EFIPTOC Definite time
1) For further reference, see Operation characteristics table
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Table 30. Directional earth-fault protection (DEFxPDEF)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
DEFLPDEF Current:±1.5% of the set value or ±0.002 × InVoltage±1.5% of the set value or ±0.002 × UnPhase angle:±2°
DEFHPDEF Current:±1.5% of the set value or ±0.002 × In(at currents in the range of 0.1…10 × In)±5.0% of the set value(at currents in the range of 10…40 × In)Voltage:±1.5% of the set value or ±0.002 × UnPhase angle:±2°
Start time 1)2) Minimum Typical Maximum
DEFHPDEFIFault = 2 × set Start value
42 ms
46 ms
49 ms
DEFLPDEFIFault = 2 × set Start value
58 ms 62 ms 66 ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Retardation time <30 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3)
Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppression
1) Set Operate delay time = 0.06 s,Operate curve type = IEC definite time, Measurement mode = default (depends on stage), current before fault = 0.0 × In, fn = 50 Hz, earth-fault current with
nominal frequency injected from random phase angle, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 × In, Start value multiples in range of 1.5...20
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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Table 31. Directional earth-fault protection (DEFxPDEF) main settings
Parameter Function Value (Range) Step
Start Value DEFLPDEF 0.010...5.000 × In 0.005
DEFHPDEF 0.10...40.00 × In 0.01
Directional mode DEFLPDEF and DEFHPDEF 1 = Non-directional2 = Forward3 = Reverse
Time multiplier DEFLPDEF 0.05...15.00 0.01
DEFHPDEF 0.05...15.00 0.01
Operate delay time DEFLPDEF 60...200000 ms 10
DEFHPDEF 40...200000 ms 10
Operating curve type1) DEFLPDEF Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19
DEFHPDEF Definite or inverse timeCurve type: 1, 3, 5, 15, 17
Operation mode DEFLPDEF and DEFHPDEF 1 = Phase angle2 = IoSin3 = IoCos4 = Phase angle 805 = Phase angle 88
1) For further reference, refer to the Operating characteristics table
Table 32. Transient/intermittent earth-fault protection (INTRPTEF)
Characteristic Value
Operation accuracy (Uo criteria with transient protection) Depending on the frequency of the measured current: fn ±2 Hz
±1.5% of the set value or ±0.002 × Uo
Operate time accuracy ±1.0% of the set value or ±20 ms
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5
Table 33. Transient/intermittent earth-fault protection (INTRPTEF) main settings
Parameter Function Value (Range) Step
Directional mode INTRPTEF 1=Non-directional2=Forward3=Reverse
-
Operate delay time INTRPTEF 40...1200000 ms 10
Voltage start value (voltage startvalue for transient EF)
INTRPTEF 0.01...0.50 × Un 0.01
Operation mode INTRPTEF 1=Intermittent EF2=Transient EF
-
Peak counter limit (Minrequirement for peak counterbefore start in IEF mode)
INTRPTEF 2...20 -
Min operate current INTRPTEF 0.01...1.00 × In 0.01
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Table 34. Negative-sequence overcurrent protection (NSPTOC)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
±1.5% of the set value or ±0.002 × In
Start time 1)2) Minimum Typical Maximum
IFault = 2 × set Start valueIFault = 10 × set Start value
23 ms15 ms
26 ms18 ms
28 ms20ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Retardation time <35 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3)
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
1) Negative sequence current before fault = 0.0, fn = 50 Hz, results based on statistical distribution of 1000 measurements
2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 × In, Start value multiples in range of 1.5...20
Table 35. Negative-sequence overcurrent protection (NSPTOC) main settings
Parameter Function Value (Range) Step
Start value NSPTOC 0.01...5.00 × In 0.01
Time multiplier NSPTOC 0.05...15.00 0.01
Operate delay time NSPTOC 40...200000 ms 10
Operating curve type1) NSPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19
1) For further reference, see Operation characteristics table
Table 36. Residual overvoltage protection (ROVPTOV)
Characteristic Value
Operation accuracy Depending on the frequency of the measured voltage: fn ±2 Hz
±1.5% of the set value or ±0.002 × Un
Start time1)2) Minimum Typical Maximum
UFault = 2 × set Start value 48 ms 51 ms 54 ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Retardation time <35 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
1) Residual voltage before fault = 0.0 × Un, fn = 50 Hz, residual voltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000
measurements2) Includes the delay of the signal output contact
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Table 37. Residual overvoltage protection (ROVPTOV) main settings
Parameter Function Value (Range) Step
Start value ROVPTOV 0.010...1.000 × Un 0.001
Operate delay time ROVPTOV 40...300000 ms 1
Table 38. Three-phase undervoltage protection (PHPTUV)
Characteristic Value
Operation accuracy Depending on the frequency of the voltage measured: fn ±2 Hz
±1.5% of the set value or ±0.002 × Un
Start time1)2) Minimum Typical Maximum
UFault = 0.9 × set Start value 62 ms 66 ms 70 ms
Reset time Typically 40 ms
Reset ratio Depends on the set Relative hysteresis
Retardation time <35 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms3)
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
1) Start value = 1.0 × Un, Voltage before fault = 1.1 × Un, fn = 50 Hz, undervoltage in one phase-to-phase with nominal frequency injected from random phase angle, results based on statistical
distribution of 1000 measurements2) Includes the delay of the signal output contact3) Minimum Start value = 0.50, Start value multiples in range of 0.90...0.20
Table 39. Three-phase undervoltage protection (PHPTUV) main settings
Parameter Function Value (Range) Step
Start value PHPTUV 0.05...1.20 × Un 0.01
Time multiplier PHPTUV 0.05...15.00 0.01
Operate delay time PHPTUV 60...300000 ms 10
Operating curve type1) PHPTUV Definite or inverse timeCurve type: 5, 15, 21, 22, 23
1) For further reference, see Operation characteristics table
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Table 40. Three-phase overvoltage protection (PHPTOV)
Characteristic Value
Operation accuracy Depending on the frequency of the measured voltage: fn ±2 Hz
±1.5% of the set value or ±0.002 × Un
Start time1)2) Minimum Typical Maximum
UFault = 1.1 × set Start value 23 ms 27 ms 31 ms
Reset time Typically 40 ms
Reset ratio Depends of the set Relative hysteresis
Retardation time <35 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms3)
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
1) Start value = 1.0 × Un, Voltage before fault = 0.9 × Un, fn = 50 Hz, overvoltage in one phase-to-phase with nominal frequency injected from random phase angle, results based on statistical
distribution of 1000 measurements2) Includes the delay of the signal output contact3) Maximum Start value = 1.20 × Un, Start value multiples in range of 1.10... 2.00
Table 41. Three-phase overvoltage protection (PHPTOV) main settings
Parameter Function Value (Range) Step
Start value PHPTOV 0.05...1.60 × Un 0.01
Time multiplier PHPTOV 0.05...15.00 0.01
Operate delay time PHPTOV 40...300000 ms 10
Operating curve type1) PHPTOV Definite or inverse timeCurve type: 5, 15, 17, 18, 19, 20
1) For further reference, see Operation characteristics table
Table 42. Positive-sequence undervoltage protection (PSPTUV)
Characteristic Value
Operation accuracy Depending on the frequency of the measured voltage: fn ±2 Hz
±1.5% of the set value or ±0.002 × Un
Start time1)2) Minimum Typical Maximum
UFault = 0.99 × set Start valueUFault = 0.9 × set Start value
52 ms44 ms
55 ms47 ms
58 ms50 ms
Reset time Typically 40 ms
Reset ratio Depends of the set Relative hysteresis
Retardation time <35 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
1) Start value = 1.0 × Un, Positive sequence voltage before fault = 1.1 × Un, fn = 50 Hz, positive sequence undervoltage with nominal frequency injected from random phase angle, results based
on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact
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Table 43. Positive-sequence undervoltage protection (PSPTUV) main settings
Parameter Function Value (Range) Step
Start value PSPTUV 0.010...1.200 × Un 0.001
Operate delay time PSPTUV 40...120000 ms 10
Voltage block value PSPTUV 0.01...1.0 × Un 0.01
Table 44. Negative-sequence overvoltage protection (NSPTOV)
Characteristic Value
Operation accuracy Depending on the frequency of the voltage measured: fn ±2 Hz
±1.5% of the set value or ±0.002 × Un
Start time1)2) Minimum Typical Maximum
UFault = 1.1 × set Start valueUFault = 2.0 × set Start value
33 ms24 ms
35 ms26 ms
37 ms28 ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Retardation time <35 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
1) Negative-sequence voltage before fault = 0.0 × Un, fn = 50 Hz, negative-sequence overvoltage with nominal frequency injected from random phase angle, results based on statistical
distribution of 1000 measurements2) Includes the delay of the signal output contact
Table 45. Negative-sequence overvoltage protection (NSPTOV) main settings
Parameter Function Value (Range) Step
Start value NSPTOV 0.010...1.000 × Un 0.001
Operate delay time NSPTOV 40...120000 ms 1
Table 46. Three-phase thermal overload protection, two time constants (T2PTTR)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
Current measurement: ±1.5% of the set value or ±0.002 x In (at currentsin the range of 0.01...4.00 x In)
Operate time accuracy1) ±2.0% of the theoretical value or ±0.50 s
1) Overload current > 1.2 x Operate level temperature
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Table 47. Three-phase thermal overload protection, two time constants (T2PTTR) main settings
Parameter Function Value (Range) Step
Temperature rise T2PTTR 0.0...200.0°C 0.1
Max temperature T2PTTR 0.0...200.0°C 0.1
Operate temperature T2PTTR 80.0...120.0% 0.1
Weighting factor p T2PTTR 0.00...1.00 0.01
Short time constant T2PTTR 6...60000 s 1
Current reference T2PTTR 0.05...4.00 × In 0.01
Operation T2PTTR OffOn
-
Table 48. Circuit breaker failure protection (CCBRBRF)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
±1.5% of the set value or ±0.002 × In
Operate time accuracy ±1.0% of the set value or ±20 ms
Reset time1) Typically 40 ms
Retardation time <20 ms
1) Trip pulse time defines the minimum pulse length
Table 49. Circuit breaker failure protection (CCBRBRF) main settings
Parameter Function Value (Range) Step
Current value (Operating phasecurrent)
CCBRBRF 0.05...1.00 × In 0.05
Current value Res (Operatingresidual current)
CCBRBRF 0.05...1.00 × In 0.05
CB failure mode (Operating modeof function)
CCBRBRF 1 = Current2 = Breaker status3 = Both
-
CB fail trip mode CCBRBRF 1 = Off2 = Without check3 = Current check
-
Retrip time CCBRBRF 0...60000 ms 10
CB failure delay CCBRBRF 0...60000 ms 10
CB fault delay CCBRBRF 0...60000 ms 10
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Table 50. Arc protection (ARCSARC)
Characteristic Value
Operation accuracy ±3% of the set value or ±0.01 × In
Operate time Minimum Typical Maximum
Operation mode = "Light+current"1)2)
9 ms3)
4 ms4)12 ms3)
6 ms4)15 ms 3)
9 ms4)
Operation mode = "Light only"2) 9 ms3)
4 ms4)10 ms3)
6 ms4)12 ms3)
7 ms4)
Reset time Typically 40 ms
Reset ratio Typically 0.96
1) Phase start value = 1.0 × In, current before fault = 2.0 × set Phase start value, fn = 50 Hz, fault with nominal frequency, results based on statistical distribution of 200 measurements
2) Includes the delay of the heavy-duty output contact3) Normal power output4) High-speed output
Table 51. Arc protection (ARCSARC) main settings
Parameter Function Value (Range) Step
Phase start value (Operatingphase current)
ARCSARC 0.50...40.00 x In 0.01
Ground start value (Operatingresidual current)
ARCSARC 0.05...8.00 x In 0.01
Operation mode ARCSARC 2=Light only3=BI controlled
Table 52. Multipurpose protection (MAPGAPC)
Characteristic Value
Operation accuracy ±1.0% of the set value or ±20 ms
Table 53. Multipurpose protection (MAPGAPC) main settings
Parameter Function Value (Range) Step
Start value MAPGAPC -10000.0...10000.0 0.1
Operate delay time MAPGAPC 0...200000 ms 100
Operation mode MAPGAPC OverUnder
-
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Table 54. Three-phase overload protection for shunt capacitor banks (COLPTOC)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz, and noharmonics
5% of the set value or 0.002 × In
Start time for overload stage1)2) Typically 75 ms
Start time for under current stage2)3) Typically 26 ms
Reset time for overload and alarm stage Typically 60 ms
Reset ratio Typically 0.96
Operate time accuracy in definite time mode 1% of the set value or ±20 ms
Operate time accuracy in inverse time mode 10% of the theoretical value or ±20 ms
Suppression of harmonics for under current stage DFT: -50 dB at f = n × fn, where n = 2,3,4,5,..
1) Harmonics current before fault = 0.5 × In, harmonics fault current 1.5 × Start value, results based on statistical distribution of 1000 measurements
2) Includes the delay of the signal output contact3) Harmonics current before fault = 1.2 × In, harmonics fault current 0.8 × Start value, results based on statistical distribution of 1000 measurements
Table 55. Three-phase overload protection for shunt capacitor banks (COLPTOC) main settings
Parameter Function Value (Range) Step
Start value overload COLPTOC 0.30...1.50 × In 0.01
Alarm start value COLPTOC 80...120% 1
Start value Un Cur COLPTOC 0.10...0.70 × In 0.01
Time multiplier COLPTOC 0.05...2.00 0.01
Alarm delay time COLPTOC 500...6000000 100
Un Cur delay time COLPTOC 100...120000 100
Table 56. Current unbalance protection for shunt capacitor banks (CUBPTOC)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
1.5% of the set value or 0.002 × In
Start time1)2) Typically 26 ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Operate time accuracy in IDMT mode 1% of the theoretical value or ±20 ms
Operate time accuracy in IDMT mode 5% of the theoretical value or ±20 ms
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2,3,4,5,..
1) Fundamental frequency current = 1.0 × In, current before fault = 0.0 × In, fault current = 2.0 × Start value, results based on statistical distribution of 1000 measurements
2) Includes the delay of the signal output contact
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Table 57. Current unbalance protection for shunt capacitor banks (CUBPTOC) main settings
Parameter Function Value (Range) Step
Alarm mode CUBPTOC 1=Normal2=Element counter
-
Start value CUBPTOC 0.01...1.00 × In 0.01
Alarm start value CUBPTOC 0.01...1.00 × In 0.01
Time multiplier CUBPTOC 0.05...15.00 0.01
Operating curve type1) CUBPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19
Operate delay time CUBPTOC 50...200000 ms 10
Alarm delay time CUBPTOC 50...200000 ms 10
1) For further reference, refer to the Operating characteristics table
Table 58. Three-phase current unbalance protection for shunt capacitor banks (HCUBPTOC)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
1.5% of the set value or 0.002 × In
Start time1)2) Typically 26 ms
Reset time Typically 40 ms
Reset ratio Typically 0.96
Operate time accuracy in definite time mode 1% of the theoretical value or ±20 ms
Operate time accuracy in IDMT mode 5% of the theoretical value or ±20 ms
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2,3,4,5,..
1) Fundamental frequency current = 1.0 × In, current before fault = 0.0 × In, fault current = 2.0 × Start value, results based on statistical distribution of 1000 measurements
2) Includes the delay of the signal output contact
Table 59. Three-phase current unbalance protection for shunt capacitor banks (HCUBPTOC) main settings
Parameter Function Value (Range) Step
Start value HCUBPTOC 0.01...1.00 × In 0.01
Alarm start value HCUBPTOC 0.01...1.00 × In 0.01
Time multiplier HCUBPTOC 0.05...15.00 0.01
Operating curve type 1) HCUBPTOC Definite or inverse timeCurve type: 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 17, 18, 19
Operate delay time HCUBPTOC 40...200000 ms 10
Alarm delay time HCUBPTOC 40...200000 ms 10
1) For further reference, refer to the Operating characteristics table
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Table 60. Shunt capacitor bank switching resonance protection, current based (SRCPTOC)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
Operate value accuracy:±3% of the set value or ±0.002 × In (for 2nd order Harmonics)±1.5% of the set value or ±0.002 × In (for 3rd order < Harmonics < 10thorder)±6% of the set value or ±0.004 × In (for Harmonics >= 10th order)
Reset time Typically 45 ms or maximum 50 ms
Retardation time Typically 0.96
Retardation time <35 ms
Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms
Suppression of harmonics -50 dB at f = fn
Table 61. Shunt capacitor bank switching resonance protection, current based (SRCPTOC) main settings
Parameter Function Value (Range) Step
Alarm start value SRCPTOC 0.03...0.50 × In 0.01
Start value SRCPTOC 0.03...0.50 × In 0.01
Tuning harmonic Num SRCPTOC 1...11 1
Operate delay time SRCPTOC 120...360000 ms 1
Alarm delay time SRCPTOC 120...360000 ms 1
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Table 62. Operation characteristics
Parameter Value (Range)
Operating curve type 1 = ANSI Ext. inv.2 = ANSI Very. inv.3 = ANSI Norm. inv.4 = ANSI Mod inv.5 = ANSI Def. Time6 = L.T.E. inv.7 = L.T.V. inv.8 = L.T. inv.9 = IEC Norm. inv.10 = IEC Very inv.11 = IEC inv.12 = IEC Ext. inv.13 = IEC S.T. inv.14 = IEC L.T. inv15 = IEC Def. Time17 = Programmable18 = RI type19 = RD type
Operating curve type (voltage protection) 5 = ANSI Def. Time15 = IEC Def. Time17 = Inv. Curve A18 = Inv. Curve B19 = Inv. Curve C20 = Programmable21 = Inv. Curve A22 = Inv. Curve B23 = Programmable
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Power quality functions
Table 63. Voltage variation (PHQVVR)
Characteristic Value
Operation accuracy ±1.5% of the set value or ±0.2% of reference voltage
Reset ratio Typically 0.96 (Swell), 1.04 (Dip, Interruption)
Table 64. Voltage unbalance (VSQVUB)
Characteristic Value
Operation accuracy ±1.5% of the set value or ±0.002 × Un
Reset ratio Typically 0.96
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Condition and supervision functions
Table 65. Circuit-breaker condition monitoring (SSCBR)
Characteristic Value
Current measuring accuracy ±1.5% or ±0.002 x In(at currents in the range of 0.1…10 x In)±5.0%(at currents in the range of 10…40 x In)
Operate time accuracy ±1.0% of the set value or ±20 ms
Travelling time measurement +10 ms / -0 ms
Table 66. Current circuit supervision (CCSPVC)
Characteristic Value
Operate time 1) <30 ms
1) Including the delay of the output contact
Table 67. Current circuit supervision (CCSPVC) main settings
Parameter Function Value (Range) Step
Start value CCSPVC 0.05...0.20 × In 0.01
Maximum operate current CCSPVC 1.00...5.00 × In 0.01
Table 68. Fuse failure supervision (SEQSPVC)
Characteristic Value
Operate time1) NPS function UFault = 1.1 × set Neg Seq voltageLev
<33 ms
UFault = 5.0 × set Neg Seq voltageLev
<18 ms
Delta function ΔU = 1.1 × set Voltage change rate <30 ms
ΔU = 2.0 × set Voltage change rate <24 ms
1) Includes the delay of the signal output contact, fn = 50 Hz, fault voltage with nominal frequency injected from random phase angle, results based on statistical distribution of 1000
measurements
Table 69. Runtime counter for machines and devices (MDSOPT)
Description Value
Motor runtime measurement accuracy1) ±0.5%
1) Of the reading, for a stand-alone relay, without time synchronization.
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Measurement functions
Table 70. Three-phase current measurement (CMMXU)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: fn ±2 Hz
±0.5% or ±0.002 × In(at currents in the range of 0.01...4.00 × In)
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…RMS: No suppression
Table 71. Sequence current measurement (CSMSQI)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: f/fn = ±2 Hz
±1.0% or ±0.002 × Inat currents in the range of 0.01...4.00 × In
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
Table 72. Residual current measurement (RESCMMXU)
Characteristic Value
Operation accuracy Depending on the frequency of the current measured: f/fn = ±2 Hz
±0.5% or ±0.002 × Inat currents in the range of 0.01...4.00 × In
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…RMS: No suppression
Table 73. Three-phase voltage measurement (VMMXU)
Characteristic Value
Operation accuracy Depending on the frequency of the voltage measured: fn ±2 HzAt voltages in range 0.01…1.15 × Un
±0.5% or ±0.002 × Un
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…RMS: No suppression
Table 74. Residual voltage measurement (RESVMMXU)
Characteristic Value
Operation accuracy Depending on the frequency of the measured current: f/fn = ±2 Hz
±0.5% or ±0.002 × Un
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…RMS: No suppression
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Table 75. Sequence voltage measurement (VSMSQI)
Characteristic Value
Operation accuracy Depending on the frequency of the voltage measured: fn ±2 HzAt voltages in range 0.01…1.15 × Un
±1.0% or ±0.002 × Un
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
Table 76. Three-phase power and energy measurement (PEMMXU)
Characteristic Value
Operation accuracy At all three currents in range 0.10…1.20 × InAt all three voltages in range 0.50…1.15 × UnAt the frequency fn ±1 Hz
±1.5% for apparent power S±1.5% for active power P and active energy1)
±1.5% for reactive power Q and reactive energy2)
±0.015 for power factor
Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…
1) |PF| >0.5 which equals |cosφ| >0.52) |PF| <0.86 which equals |sinφ| >0.5
Table 77. Frequency measurement (FMMXU)
Characteristic Value
Operation accuracy ±10 mHz(in measurement range 35...75 Hz)
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Other functions
Table 78. Pulse timer function block (PTGAPC)
Characteristic Value
Operate time accuracy ±1.0% of the set value or ±20 ms
Table 79. Time delay off (8 pcs) (TOFPAGC)
Characteristic Value
Operate time accuracy ±1.0% of the set value or ±20 ms
Table 80. Time delay on (8 pcs) (TONGAPC)
Characteristic Value
Operate time accuracy ±1.0% of the set value or ±20 ms
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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21. Local HMIThe relay is available with two optional displays, a large one anda small one. The large display is suited for relay installationswhere the front panel user interface is frequently used and asingle line diagram is required. The small display is suited forremotely controlled substations where the relay is onlyoccasionally accessed locally via the front panel user interface.
Both LCD displays offer front-panel user interface functionalitywith menu navigation and menu views. However, the largedisplay offers increased front-panel usability with less menuscrolling and improved information overview. In addition, thelarge display includes a user-configurable single line diagram(SLD) with position indication for the associated primaryequipment. Depending on the chosen standard configuration,the relay displays the related measuring values, apart from the
default single line diagram. The SLD view can also be accessedusing the Web browser-based user interface. The default SLDcan be modified according to user requirements by using theGraphical Display Editor in PCM600. The user can create up to10 SLD pages.
The local HMI includes a push button (L/R) for local/remoteoperation of the relay. When the relay is in the local mode, it canbe operated only by using the local front panel user interface.When the relay is in the remote mode, it can executecommands sent from a remote location. The relay supports theremote selection of local/remote mode via a binary input. Thisfeature facilitates, for example, the use of an external switch atthe substation to ensure that all relays are in the local modeduring maintenance work and that the circuit breakers cannotbe operated remotely from the network control center.
IECA070904 V3 EN
Figure 11. Small display
IECA070901 V3 EN
Figure 12. Large display
Table 81. Small display
Character size1) Rows in the view Characters per row
Small, mono-spaced (6x12 pixels) 5 20
Large, variable width (13x14 pixels) 3 8 or more
1) Depending on the selected language
Table 82. Large display
Character size1) Rows in the view Characters per row
Small, mono-spaced (6x12 pixels) 10 20
Large, variable width (13x14 pixels) 7 8 or more
1) Depending on the selected language
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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22. Mounting methodsBy means of appropriate mounting accessories the standardrelay case for the 615 series relay can be flush mounted, semi-flush mounted or wall mounted. The flush mounted and wallmounted relay cases can also be mounted in a tilted position(25°) using special accessories.
Further, the relays can be mounted in any standard 19”instrument cabinet by means of 19” mounting panels availablewith cut-outs for one or two relays.Alternatively, the relay canbe mounted in 19” instrument cabinets by means of 4UCombiflex equipment frames.
For the routine testing purposes, the relay cases can beequipped with test switches, type RTXP 18, which can bemounted side by side with the relay cases.
Mounting methods:
• Flush mounting• Semi-flush mounting• Semi-flush mounting in a 25° tilt• Rack mounting• Wall mounting• Mounting to a 19" equipment frame• Mounting with a RTXP 18 test switch to a 19" rack
Panel cut-out for flush mounting:• Height: 161.5 ±1 mm• Width: 165.5 ±1 mm
48
177
160
177
153
164
IECA070900 V4 EN
Figure 13. Flush mounting
98
177
160
186
103
IECA070903 V4 EN
Figure 14. Semi-flush mounting
230
107
25°
133
190
IECA070902 V4 EN
Figure 15. Semi-flush with a 25º tilt
23. Relay case and plug-in unitFor safety reasons, the relay cases for current measuring relaysare provided with automatically operating contacts for short-circuiting the CT secondary circuits when a relay unit iswithdrawn from its case. The relay case is further provided witha mechanical coding system preventing current measuringrelay units from being inserted into a relay case for a voltage
measuring relay unit and vice versa, that is, the relay cases areassigned to a certain type of plug-in unit.
24. Selection and ordering dataUse the ABB Library to access the selection and orderinginformation and to generate the order number.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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25. Accessories and ordering data
Table 83. Mounting accessories
Item Order number
Semi-flush mounting kit 1MRS050696
Wall mounting kit 1MRS050697
Inclined semi-flush mounting kit 1MRS050831
19” rack mounting kit with cut-out for one relay 1MRS050694
19” rack mounting kit with cut-out for two relays 1MRS050695
Mounting bracket for one relay with test switch RTXP in 4U Combiflex (RHGT 19” variant C) 2RCA022642P0001
Mounting bracket for one relay in 4U Combiflex (RHGT 19” variant C) 2RCA022643P0001
19” rack mounting kit for one relay and one RTXP18 test switch (the test switch is not included in the delivery) 2RCA021952A0003
19” rack mounting kit for one relay and one RTXP24 test switch (the test switch is not included in the delivery) 2RCA022561A0003
Replacement kit for a Strömberg SP_J40 series relay (cut-out in the center of the installation plate) 2RCA027871A0001
Replacement kit for a Strömberg SP_J40 series relay (cut-out on the left or the right of the installation plate) 2RCA027874A0001
Replacement kit for two Strömberg SP_J3 series relays 2RCA027880A0001
19” rack replacement kit for Strömberg SP_J3/J6 series relays (one cut-out) 2RCA027894A0001
19” rack replacement kit for Strömberg SP_J3/J6 series relays (two cut-outs) 2RCA027897A0001
Replacement kit for a Strömberg SP_J6 series relay 2RCA027881A0001
Replacement kit for three BBC S_ series relays 2RCA027882A0001
Replacement kit for a SPA 300 series relay 2RCA027885A0001
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26. ToolsThe protection relay is delivered as a pre-configured unit. Thedefault parameter setting values can be changed from the front-panel user interface, the Web browser-based user interface(Web HMI) or the PCM600 tool in combination with the relay-specific connectivity package.
The Protection and Control IED Manager PCM600 offersextensive relay configuration functions such as relay signalconfiguration, application configuration, graphical displayconfiguration including single line diagram configuration, andIEC 61850 communication configuration including horizontalGOOSE communication.
When the Web browser-based user interface is used, theprotection relay can be accessed either locally or remotely
using a Web browser (Internet Explorer). For security reasons,the Web browser-based user interface is disabled by defaultbut it can be enabled via the front-panel user interface. TheWeb HMI functionality can be limited to read-only access.
The relay connectivity package is a collection of software andspecific relay information, which enable system products andtools to connect and interact with the protection relay. Theconnectivity packages reduce the risk of errors in systemintegration, minimizing device configuration and setup times.Further, the connectivity packages for protection relays of thisproduct series include a flexible update tool for adding oneadditional local HMI language to the protection relay. Theupdate tool is activated using PCM600, and it enables multipleupdates of the additional HMI language, thus offering flexiblemeans for possible future language updates.
Table 84. Tools
Configuration and setting tools Version
PCM600 2.6 (Rollup 20150626) or later
Web browser-based user interface IE 8.0, IE 9.0, IE 10.0 or IE 11.0
REV615 Connectivity Package 5.1 or later
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Table 85. Supported functions
Function Web HMI PCM600
Relay parameter setting ● ●
Saving of relay parameter settings in the relay ● ●
Signal monitoring ● ●
Disturbance recorder handling ● ●
Alarm LED viewing ● ●
Access control management ● ●
Relay signal configuration (Signal Matrix) - ●
Modbus® communication configuration (communication management) - ●
DNP3 communication configuration (communication management) - ●
IEC 60870-5-103 communication configuration (communicationmanagement) - ●
Saving of relay parameter settings in the tool - ●
Disturbance record analysis - ●
XRIO parameter export/import - ●
Graphical display configuration - ●
Application configuration - ●
IEC 61850 communication configuration, GOOSE (communicationconfiguration) - ●
Phasor diagram viewing ● -
Event viewing ● ●
Saving of event data on the user's PC ● ●
Online monitoring - ●● = Supported
27. Cyber securityThe relay supports role based user authentication andauthorization. It can store 2048 audit trail events to a non-volatile memory. The non-volatile memory is based on amemory type which does not need battery backup or regularcomponent exchange to maintain the memory storage. FTP
and Web HMI use TLS encryption with a minimum of 128 bit keylength protecting the data in transit. In this case the usedcommunication protocols are FTPS and HTTPS. All rearcommunication ports and optional protocol services can bedeactivated according to the desired system setup.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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28. Terminal diagrams
REV615
X13Light sensor input 1 1)
X14Light sensor input 2 1)
X15Light sensor input 3 1)
1) Optional2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached3) BIO0005 Module (8BI+4BO) Alternative Module BIO0007 (8BI+3HSO)4) BIO0006 Module (6BI+3BO) Alternative Module RTD0001 (6RTD+2mA)
16
17
1918
X100
67
89
10
111213
15
14
2
1
3
45
22
212324
SO2
TCS2
PO4
SO1
TCS1
PO3
PO2
PO1
IRF
+
-Uaux
20
X110
34
56
7
89
10BI 6
BI 5
BI 4
BI 3
BI 2
BI 8
BI 712
13
11
BI 112
X110
16
14
15
19
17
18
22
20
21
SO3
SO2
SO1
23SO4
24
2)
X120
1
23
45
67
89
1011
1213
14
IL1unb1/5A
N
IL2unb
IL1
IL2
IL3
Io
1/5A
N1/5A
N1/5A
N1/5A
N1/5A
N1/5A
N
IL3unb
3)
3)
X130
12
3
45
6BI 4
BI 3
BI 2
BI 1
BI 6
BI 58
9
7
X130
12
10
11
15
13
14
18
16
17
SO3
SO2
SO1
4)
4)
GUID-E075C9E1-5D32-4556-ADD7-8B64EF861FA8 V1 EN
Figure 16. Terminal diagram for standard configuration A
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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REV615
X13Light sensor input 1 1)
X14Light sensor input 2 1)
X15Light sensor input 3 1)
1) Optional2) The IED features an automatic short-circuit mechanism in the CT connector when plug-in unit is detached3) BIO0005 Module (8BI+4BO) Alternative Module BIO0007 (8BI+3HSO)4) AIM0006 Module (5U+4BI) Alternative Module AIM0003 (5U+2RTD+1mA)
16
17
1918
X100
67
89
10
111213
15
14
2
1
3
45
22
212324
SO2
TCS2
PO4
SO1
TCS1
PO3
PO2
PO1
IRF
+
-Uaux
20
X110
34
56
7
89
10BI 6
BI 5
BI 4
BI 3
BI 2
BI 8
BI 712
13
11
BI 112
X110
16
14
15
19
17
18
22
20
21
SO3
SO2
SO1
23SO4
24
2)
X120
1
23
45
67
89
1011
1213
14
IL1unb1/5A
N
IL2unb
IL1
IL2
IL3
Io
1/5A
N1/5A
N1/5A
N1/5A
N1/5A
N1/5A
N
IL3unb
3)
3)
X13012
34
56
BI 4
BI 3
BI 2
BI 1
87
9101112
UoB
1314
U1
1516
U2
1718
U3
UoN
N
N
N
60 -
N
210V
60 -210V
60 -210V
60 -210V
60 -210V
4)
GUID-71A7F7FA-9605-46FE-A7EF-B53142C4EE9F V1 EN
Figure 17. Terminal diagram for standard configuration B
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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29. CertificatesDNV GL has issued an IEC 61850 Edition 2 Certificate Level A1
for Relion® 615 series. Certificate number: 7410570I-OPE/INC15-1136.
DNV GL has issued an IEC 61850 Edition 1 Certificate Level A1
for Relion® 615 series. Certificate number: 74105701-OPE/INC15-1145.
Additional certificates can be found on the product page.
30. ReferencesThe www.abb.com/substationautomation portal providesinformation on the entire range of distribution automationproducts and services.
You will find the latest relevant information on the REV615protection and control relay on the product page. Scroll downthe page to find and download the related documentation.
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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31. Functions, codes and symbols
Table 86. Functions included in the relay
Function IEC 61850 IEC 60617 IEC-ANSI
Protection
Three-phase non-directional overcurrent protection, lowstage
PHLPTOC1 3I> (1) 51P-1 (1)
Three-phase non-directional overcurrent protection, highstage
PHHPTOC1 3I>> (1) 51P-2 (1)
PHHPTOC2 3I>> (2) 51P-2 (2)
Three-phase non-directional overcurrent protection,instantaneous stage
PHIPTOC1 3I>>> (1) 50P/51P (1)
Non-directional earth-fault protection, low stage EFLPTOC1 Io> (1) 51N-1 (1)
EFLPTOC2 Io> (2) 51N-1 (2)
Non-directional earth-fault protection, high stage EFHPTOC1 Io>> (1) 51N-2 (1)
Non-directional earth-fault protection, instantaneous stage EFIPTOC1 Io>>> (1) 50N/51N (1)
Directional earth-fault protection, low stage DEFLPDEF1 Io> -> (1) 67N-1 (1)
DEFLPDEF2 Io> -> (2) 67N-1 (2)
Directional earth-fault protection, high stage DEFHPDEF1 Io>> -> (1) 67N-2 (1)
Transient/intermittent earth-fault protection INTRPTEF1 Io> -> IEF (1) 67NIEF (1)
Negative-sequence overcurrent protection NSPTOC1 I2> (1) 46 (1)
NSPTOC2 I2> (2) 46 (2)
Residual overvoltage protection ROVPTOV1 Uo> (1) 59G (1)
ROVPTOV2 Uo> (2) 59G (2)
ROVPTOV3 Uo> (3) 59G (3)
Three-phase undervoltage protection PHPTUV1 3U< (1) 27 (1)
PHPTUV2 3U< (2) 27 (2)
Three-phase overvoltage protection PHPTOV1 3U> (1) 59 (1)
PHPTOV2 3U> (2) 59 (2)
Positive-sequence undervoltage protection PSPTUV1 U1< (1) 47U+ (1)
Negative-sequence overvoltage protection NSPTOV1 U2> (1) 47O- (1)
Three-phase thermal overload protection, two timeconstants
T2PTTR1 3Ith>T/G/C (1) 49T/G/C (1)
Circuit breaker failure protection CCBRBRF1 3I>/Io>BF (1) 51BF/51NBF (1)
Master trip TRPPTRC1 Master Trip (1) 94/86 (1)
TRPPTRC2 Master Trip (2) 94/86 (2)
TRPPTRC3 Master Trip (3) 94/86 (3)
TRPPTRC4 Master Trip (4) 94/86 (4)
TRPPTRC5 Master Trip (5) 94/86 (5)
Arc protection ARCSARC1 ARC (1) 50L/50NL (1)
ARCSARC2 ARC (2) 50L/50NL (2)
ARCSARC3 ARC (3) 50L/50NL (3)
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Table 86. Functions included in the relay, continued
Function IEC 61850 IEC 60617 IEC-ANSI
Multipurpose protection MAPGAPC1 MAP (1) MAP (1)
MAPGAPC2 MAP (2) MAP (2)
MAPGAPC3 MAP (3) MAP (3)
MAPGAPC4 MAP (4) MAP (4)
MAPGAPC5 MAP (5) MAP (5)
MAPGAPC6 MAP (6) MAP (6)
MAPGAPC7 MAP (7) MAP (7)
MAPGAPC8 MAP (8) MAP (8)
MAPGAPC9 MAP (9) MAP (9)
MAPGAPC10 MAP (10) MAP (10)
MAPGAPC11 MAP (11) MAP (11)
MAPGAPC12 MAP (12) MAP (12)
MAPGAPC13 MAP (13) MAP (13)
MAPGAPC14 MAP (14) MAP (14)
MAPGAPC15 MAP (15) MAP (15)
MAPGAPC16 MAP (16) MAP (16)
MAPGAPC17 MAP (17) MAP (17)
MAPGAPC18 MAP (18) MAP (18)
Three-phase overload protection for shunt capacitor banks COLPTOC1 3I> 3I< (1) 51C/37 (1)
Current unbalance protection for shunt capacitor banks CUBPTOC1 dI>C (1) 51NC-1 (1)
Three-phase current unbalance protection for shuntcapacitor banks
HCUBPTOC1 3dI>C (1) 51NC-2 (1)
Shunt capacitor bank switching resonance protection,current based
SRCPTOC1 TD> (1) 55TD (1)
Power quality
Current total demand distortion CMHAI1 PQM3I (1) PQM3I (1)
Voltage total harmonic distortion VMHAI1 PQM3U (1) PQM3V (1)
Voltage variation PHQVVR1 PQMU (1) PQMV (1)
Voltage unbalance VSQVUB1 PQUUB (1) PQVUB (1)
Control
Circuit-breaker control CBXCBR1 I <-> O CB (1) I <-> O CB (1)
Disconnector control DCXSWI1 I <-> O DCC (1) I <-> O DCC (1)
DCXSWI2 I <-> O DCC (2) I <-> O DCC (2)
Earthing switch control ESXSWI1 I <-> O ESC (1) I <-> O ESC (1)
Disconnector position indication DCSXSWI1 I <-> O DC (1) I <-> O DC (1)
DCSXSWI2 I <-> O DC (2) I <-> O DC (2)
DCSXSWI3 I <-> O DC (3) I <-> O DC (3)
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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Table 86. Functions included in the relay, continued
Function IEC 61850 IEC 60617 IEC-ANSI
Earthing switch indication ESSXSWI1 I <-> O ES (1) I <-> O ES (1)
ESSXSWI2 I <-> O ES (2) I <-> O ES (2)
Condition monitoring and supervision
Circuit-breaker condition monitoring SSCBR1 CBCM (1) CBCM (1)
Trip circuit supervision TCSSCBR1 TCS (1) TCM (1)
TCSSCBR2 TCS (2) TCM (2)
Current circuit supervision CCSPVC1 MCS 3I (1) MCS 3I (1)
Fuse failure supervision SEQSPVC1 FUSEF (1) 60 (1)
Runtime counter for machines and devices MDSOPT1 OPTS (1) OPTM (1)
Measurement
Disturbance recorder RDRE1 DR (1) DFR (1)
Load profile record LDPRLRC1 LOADPROF (1) LOADPROF (1)
Fault record FLTRFRC1 FAULTREC (1) FAULTREC (1)
Three-phase current measurement CMMXU1 3I (1) 3I (1)
Sequence current measurement CSMSQI1 I1, I2, I0 (1) I1, I2, I0 (1)
Residual current measurement RESCMMXU1 Io (1) In (1)
Three-phase voltage measurement VMMXU1 3U (1) 3V (1)
Residual voltage measurement RESVMMXU1 Uo (1) Vn (1)
RESVMMXU2 Uo (2) Vn (2)
Sequence voltage measurement VSMSQI1 U1, U2, U0 (1) V1, V2, V0 (1)
Three-phase power and energy measurement PEMMXU1 P, E (1) P, E (1)
RTD/mA measurement XRGGIO130 X130 (RTD) (1) X130 (RTD) (1)
Frequency measurement FMMXU1 f (1) f (1)
IEC 61850-9-2 LE sampled value sending SMVSENDER SMVSENDER SMVSENDER
IEC 61850-9-2 LE sampled value receiving (voltagesharing)
SMVRECEIVER SMVRECEIVER SMVRECEIVER
Other
Minimum pulse timer (2 pcs) TPGAPC1 TP (1) TP (1)
TPGAPC2 TP (2) TP (2)
TPGAPC3 TP (3) TP (3)
TPGAPC4 TP (4) TP (4)
Minimum pulse timer (2 pcs, second resolution) TPSGAPC1 TPS (1) TPS (1)
Minimum pulse timer (2 pcs, minute resolution) TPMGAPC1 TPM (1) TPM (1)
Pulse timer (8 pcs) PTGAPC1 PT (1) PT (1)
PTGAPC2 PT (2) PT (2)
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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Table 86. Functions included in the relay, continued
Function IEC 61850 IEC 60617 IEC-ANSI
Time delay off (8 pcs) TOFGAPC1 TOF (1) TOF (1)
TOFGAPC2 TOF (2) TOF (2)
TOFGAPC3 TOF (3) TOF (3)
TOFGAPC4 TOF (4) TOF (4)
Time delay on (8 pcs) TONGAPC1 TON (1) TON (1)
TONGAPC2 TON (2) TON (2)
TONGAPC3 TON (3) TON (3)
TONGAPC4 TON (4) TON (4)
Set-reset (8 pcs) SRGAPC1 SR (1) SR (1)
SRGAPC2 SR (2) SR (2)
SRGAPC3 SR (3) SR (3)
SRGAPC4 SR (4) SR (4)
Move (8 pcs) MVGAPC1 MV (1) MV (1)
MVGAPC2 MV (2) MV (2)
Generic control point (16 pcs) SPCGAPC1 SPC (1) SPC (1)
SPCGAPC2 SPC (2) SPC (2)
Analog value scaling SCA4GAPC1 SCA4 (1) SCA4 (1)
SCA4GAPC2 SCA4 (2) SCA4 (2)
SCA4GAPC3 SCA4 (3) SCA4 (3)
SCA4GAPC4 SCA4 (4) SCA4 (4)
Integer value move MVI4GAPC1 MVI4 (1) MVI4 (1)
32. Document revision history
Document revision/date Product version History
A/2014-01-24 5.0 First release
B/2015-10-30 5.0 FP1 Content updated to correspond to the product version
Capacitor Bank Protection and Control 1MRS757952 BREV615 Product version: 5.0 FP1
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58
Contact us
ABB OyMedium Voltage Products,Distribution AutomationP.O. Box 699FI-65101 VAASA, FinlandPhone +358 10 22 11Fax +358 10 22 41094
www.abb.com/mediumvoltage
www.abb.com/substationautomation
ABB India Limited,Distribution AutomationManeja WorksVadodara-390013, IndiaPhone +91 265 6724402Fax +91 265 6724423
www.abb.com/mediumvoltage
www.abb.com/substationautomation
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